Good morning. My
name
is
Lorrie,
and
I'll
be
your
conference
facilitator
today.
Welcome
to
Frontera
Energy's
Fourth
Quarter
2021
and
Year-End
Operating
and
Financial
Results
Conference
Call.
All
lines
are
currently
on
mute
to
prevent
any
background
noise.
The
call
is
scheduled
for
60
Minutes.
I
would
like
to
remind
you
that
this
conference
call
is
being
recorded
today,
and
it's
also
available
through
audio
webcast
on
the
company's
website.
After
the
speakers'
remarks,
there
will
be
time
for
questions.
Analysts
and
investors
are
reminded
that
any
additional
questions
can
be
directed
to
the
company
at
ir@fronteraenergy.ca.
This
call
contains
forward-looking
information
within
the
meaning
of
applicable
Canadian
security
laws
relating
to
activities,
events
or
developments
the
company
believes
or
expects
will
or
may
occur
in
the
future.
Forward-looking
information
reflects
the
current
expectations,
assumptions
and
beliefs
of
the
company
based
on
information
currently
available
to
it.
Also,
the
company
believes
the
assumptions
are
reasonable.
Forward-looking
information
is
not
a
guarantee
of
future
performance.
Forward-looking
information
is
subject
to
a
number
of
risks
and
uncertainties
that
may
cause
the
actual
results
of
the
company
to
differ
materially
from
those
discussed
in
the
forward-looking
information.
The
company's
MD&A
for
the
year
ended
December
31, 2021,
and
the
company's
Annual
Information
Form
dated
March
2, 2022,
and
other
documents
it
files
from
time
to
time
with
securities
regulatory
authorities
describe
the
risks,
uncertainties,
materials
assumptions
and
other
factors
that
could
influence
actual
results.
Any
forward-looking
information
speaks
only
as
of
the
date
on
which
it
is
made
and
the
company
disclaims
any
intent
or
obligation
to
update
any
forward-looking
information
except
as
required
by
law.
I
would
now
like
to
turn
the
call
over
to
Mr.
Gabriel
de
Alba,
Chairman
of
the
Board
of
Frontera
Energy.
Please
go
ahead,
sir.
G
Gabriel de Alba
Chairman, Frontera Energy Corp.
Thank you
operator
and
thank
you
everyone
for
joining
today's
conference
call
to
review
Frontera's
fourth
quarter
and
year-end
operating
and
financial
results.
Joining
me
on
the call
are
Orlando
Cabrales,
Frontera's
CEO;
Alejandro
Piñeros,
Frontera's CFO. Also
available
to
answer
questions
at
the
end
of
the
call,
we
have
Victor
Vega,
VP
of
Field
Development,
Reservoir
Management
and
Exploration;
and
Regan
Palsgrove,
Head
of
Exploration.
Frontera
continues
to
deliver
on
its
strategic,
operational
and
financial
objectives.
In
2021,
the
company
generated
$373.2
million
of
EBITDA,
an
increase
of
117%
compared
to
2020
and
within
the
company's
tightened
and
increased full-year
operating
EBITDA
guidance
range.
Frontera
averaged
37,818
barrels
per
day,
in
line
with
2021
guidance.
Frontera
recorded
net income
of
$628.1
million
in
2021,
primarily
due
to
impairment
reversals.
The
company
released
approximately
$105.6
million
of
restricted
cash,
increased
its
uncollateralized
credit
lines
to
$89.6
million
at
year-end
and
repurchased
approximately
3.86
million
or
7.4%
of
its
public
float
for
cancellation
for
approximately
$21.5
million
under
its
current
NCIB
as
of
December
31, 2021.
The company
completed
the
pipeline
Conciliation
Agreement,
which
eliminated
more
than
$1
billion
in
contingent
liabilities.
Frontera's
production
costs
averaged
$11.46
per
barrel
and
its
transportation
costs
averaged
$10.43
per
barrel,
both
within
its
2021
guidance
ranges.
Importantly,
Frontera
achieved
98%
of
its
2021
ESG
goals,
including
offsetting
41%
of
its
emissions
through
carbon
credits
and
preserving
and
restoring
765
new
hectares
of
key
connectivity
corridors
in
Casanare
and
Meta
Departments
in
Colombia.
I'm
extremely proud
of
our
fourth
quarter
and
year-end
2021
results.
I
would
like
to
acknowledge
the
hard
work
and
dedication
of
entire
Frontera
team,
its
management
and
its
Board
of Directors
for
their
efforts
in
helping
the
company
achieve
such
positive
results.
I
will
now
turn
the
call
over
to
Orlando
Cabrales,
Frontera's
CFO
(sic) [Frontera's CEO] (00:05:02);
and
our
CFO,
Alejandro
Piñeros,
who
will
share
their
views
on
our
fourth
quarter
and
year-end
results.
Orlando?
O
Orlando Cabrales Segovia
Thank
you Gabriel
and
good
morning,
everyone.
Frontera
delivered
strong
fourth
quarter
financial
and
operational
results.
Production
averaged
88,605
boe
per
day (sic) [38,605 boe per day] (00:05:24),
up
6%
compared
to
the
previous
quarter,
and
the
company's
year-end
production
exit
rate
was
40,457
boe
per
day
excluding
Petrosud,
in
line
with
the
company's
production
guidance.
Frontera's
daily
production
on
March
1
of
this
year
was
approximately
42,000
boe
per
day
and
the
company's
year-to-date
average
production
is
approximately
40,500
boe per
day.
During
the fourth
quarter,
Frontera
began
early
production
of
2,400
boe
per
day
plus
at
La
Belleza
discovery
on
VIM-1,
acquired
100%
of
the
issued
and
outstanding
shares
in
Petrosud,
which
added
1,300
boe
per
day
of
production.
We
also
signed
an
agreement
to
acquire
the
remaining
35%
interest
in
el
Dificil
block
held
by
PCR,
which
will add
an
additional
500
boe
per
day
of
production
when
the
deal
closes
in
the
second
half
of this
year.
We
also
discovered hydrocarbon
bearing
reservoirs
in
multiple
formations
at
the
Jandaya-1
exploration
well
in
Ecuador. Subsequent
to
year-end
we
were
awarded
Block
VIM-46
in
the
2021
Colombia
Bid
Round.
And
importantly,
we
announced
that
our
JV
in
Guyana
had
discovered
approximately
200
feet
of
net
pay
with
multiple
horizons
at
the
company's
potentially
transformational
Kawa-1
exploration
well,
offshore
Guyana.
Compared
to
the
prior quarter,
cash
provided
by
operating
activities
increased
by
43%.
The
company's
operating
netback
increased
by
26%.
Our
net
sales
realized
price
increased
17%
and
the
company's
transportation
cost
per
barrel
decreased
12%.
Operationally,
in
the fourth
quarter
of
2021,
the
company
drilled
14
development
wells,
including
12
at
Quifa
and 2
at
Guatiquia
and
completed
56
workovers
and
well
services
at
Quifa,
Guatiquia,
Canaguaro,
Abanico,
Corcel,
Cajua,
Cravoviejo, Cubiro
and
Casimena.
In 2021, the
company
drilled
42
producer
wells,
3
injector
wells
and
completed
148
workovers
and
well
services.
We
also
delivered
solid
results
in
2021.
The
company
replaced
157%
of
net
1P
reserves
and
105%
of
net
2P
reserves
and
extended
our
net
1P
reserve
life
index
to
8.7
years
and
our
net
2P
reserve
life
index
to
13.3
years.
We
increased
our
net
2P
natural
gas
and
associated
natural
gas
liquid
reserves
by
105%
to
[ph]
19-point
million
boe
(00:09:25) further
diversifying
Frontera's
future
production
mix.
The
net
present value
at
a
10%
discount
on
December
31,
2021,
of
the
company's
2P
reserves
increased
by
61%
to $3,036
million
before
tax
due
in
part
to
higher
Brent
prices
year-over-year,
but
also
greater
operational
and
development
cost
stability.
I
would
talk about
our
Colombian
operational
activities
in
more
detail
in
a
minute,
but
first let
me
spend
a
few
moments
discussing
our
potentially
transformational
Kawa-1
exploration
well
in
offshore
Guyana.
Frontera,
through
its
joint
venture
with
CGX in
the
Corentyne
block
offshore
Guyana
have
safely
completed
exploration
activities
at the
Kawa-1
exploration
well.
In
line
with
our
exploratory
objectives,
the
well
has
now
been
safely
plugged
and
abandoned
and
the
Maersk
Discover
drilling
rig
has
been
released
from
the
Kawa-1
location.
Only
a
single
lost
time
injury
was
recorded
throughout
Kawa-1
well
operations.
The
final
cost
of
the
Kawa-1
exploration
well
was
$141
million.
The
Kawa-1
well
was
drilled
to
a
total depth
of
21,578
feet
in
the
northern
section
of
the
Corentyne
block.
Drilling
results
confirm
the
presence
of
an
active
hydrocarbon
system
at
the
Kawa-1
location.
Successful
wireline
logging
runs
confirmed
net
pay
of
approximately
200
feet
within
the Maastrichtian,
the
Campanian,
the
Santonian
and
the
Coniacian
horizons. These
intervals
are
similar
in
age
and
can
be
correlated
using
regional
seismic
data
to
recent
successes
in
Block
58
in
Suriname
and
Stabroek
Block
in
Guyana.
The
JV
did
not
get
MDT
data
or
sidewall
core
samples
and
has
engaged
an
independent
third-party
to
complete
further
detailed
studies
and
laboratory
analysis
on
drilling
cuttings
from
the
Santonian,
Campanian
and
Maastrichtian
intervals
and
well-bore
fluid
samples
to
evaluate
in
situ
hydrocarbons.
Preliminary
results
from
the
Santonian
interval
indicate
the
presence
of
liquid
hydrocarbons
in
the
reservoir.
Results
from
the
Campanian and
Maastrichtian
intervals
are
pending.
Kawa-1
well
results
have
improved
the
JV understanding
of
the
operational
and
geological
complexities
of
the
basin
and
will
help
reduce
the
technical
risks
of
the
Wei-1
exploration
well.
Given
the initial
positive
results
at
the
Kawa-1
well
the
JV
is moving
forward
with
its
second
exploration
well,
Wei-1
on
the
Corentyne
block.
The
JV
has begun
the
integration
of
detailed
seismic
and
lithological analysis
and
pore
pressure
studies
from
the
Kawa-1
well
into
drilling
preparations
in
advance of
spudding
the
Wei-1
exploration
well
which
will
be
spud
in
the
second half
of
2022. The
Wei-1
exploration
well
will
target
Campanian
and
Santonian
aged
stacked
channels
in
the
western
fan complex
in
the
northern
section
of
the
Corentyne
block.
Data
from both
the
Kawa-1
and Wei-1
wells
will
inform
future
activities
and
potential
appraisal/development
decisions.
On
February
14, 2022,
the
JV announced
that
as
a
result
of
the
initial
positive
results
at
the
Kawa-1
exploration
well,
the
JV will
focus
on
the
significant
exploration
opportunities
in
the
Corentyne
block
and
will
not
engage
in
drilling
activities
on
the
Demerara
block in
2022. CGX
is
currently
assessing
several
strategic
opportunities
to
obtain
additional
financing
to
meet
the
costs
of
the
drilling program.
Now,
I
would
like
to
discuss production
on
our
Colombian
operations.
Production
averaged
38,605
boe
per
day
in
the
fourth
quarter,
up
6%
compared
to
the
prior
quarter.
Currently,
the
company
has
five
drilling
rigs,
five
workover rigs
active
at its
Quifa,
Coralillo,
Corcel, Copa
and
Guaduas
operations
in
Colombia
and
at
the
Perico block
in
Ecuador.
At
Quifa,
current
production
is
approximately
16,100
barrels
per
day
of
heavy
crude
oil.
The
company
drills
12 development
wells
at
Quifa
in
the
fourth
quarter
of
2021.
In
total,
the
company
drilled
25
development
wells
and
2
injector
wells
at
Quifa
in
2021.
Frontera
also
continued
to
recover
water
disposal
levels
in
the
fourth
quarter
by
performing
interventions
in
storm
water
disposal
wells
at
different
injection
layers.
At
Guatiquia,
current
production
is
approximately
9,400 barrels
per
day
of
light
and
medium
crude
oil.
The
company
successfully
completed
the
Coralillo-9
well
in
the
fourth
quarter
which
is
currently
producing
700
barrels per
day.
Frontera
also
completed
Coralillo-15
in
the
fourth
quarter
which
began
production
of
600
barrels per
day
in
January of
this
year.
At
CPE-6,
current
production
is
approximately
5,000
barrels
per
day
of
heavy
crude
oil.
In
the
fourth quarter,
we
began
operations
on
our
facilities expansion
strategy.
On
the
VIM-1
Block,
production
from
La
Belleza
discovery
began
on
November
8, 2021,
with
gross
rates
of
approximately
2,400
boe
per
day.
The
Planadas-1
exploration
well
was
drilled
to
a
measured depth
of
13,700
feet,
but
yielded
no
hydrocarbons.
Turning
our
attention
to
Ecuador.
On
December
7
of
last
year,
Frontera spud
the
Jandaya-1
exploration
well
on
the
Perico
block
in
Ecuador.
This
was
among
the
first
wells
drilled
in
the
country
on
acreage
awarded
through
the
2019
Intracampos
Bid
Round.
The
well
was
drilled
to
a
total
depth
of
10,975
feet
encountering
a
total
of
78
feet
vertical
depth
of
potential
hydrocarbon
bearing
reservoir
in
three
formations.
Production
tests in
the
lower
Hollin
formation
have
produced
882
barrels
per
day
with
a
1.7%
water cut,
after
29
days
of
testing.
Development planning
activities
and
permitted
work
is
under
way
in advance
of
long-term
testing
of
at
least
six
months
or
a
longer
period
of
time
if
approved
by
authorities.
On January
28
of
this
year, Frontera
spud
its
second
exploration
well
called
Tui-1
in
the
southern
portion
of
the
Perico
block.
The
Tui-1
exploration
well
is
expected
to
be
drilled
to
a
total
debt
of
10,972
feet
and
is
targeting
the
same
formations
as the
Jandaya-1
well.
Additional
prospects
on
the
Perico
block
have
been
identified
and
are
being
matured
for
future
drilling.
Frontera's
acreage
position
and
initial
positive
results
in
Ecuador
provided
the
company
with
flexibility,
optionality
and
a
potential
future
platform
for
growth.
I
would
now
like
to
turn
the
call
over
to
Alejandro
Piñeros,
Frontera's
CFO,
to
discuss
our
fourth
quarter and
year-end
financial
results.
A
Alejandro Piñeros
Chief Financial Officer, Frontera Energy Corp.
Thank
you,
Orlando.
Frontera's
operating
EBITDA
was
$148.3
million
in
the
fourth
quarter,
up
104%
compared
to
the
prior
quarter.
The
increase
quarter-over-quarter
was
primarily
as
a
result
of
two
more
cargoes
sold
during
the
fourth
quarter
of
2021.
Frontera
generated
$373.2
million
of
EBITDA
in
2021,
up
117%
compared
to
2020
and
in
line
with
guidance
of
$360
million
to
$380 million.
The company's
total
cash
position
as
at
December
31, 2021,
was
$320.8
million
compared
to
$419.5
million
at
September
30, 2021.
Cash
utilization
during
the
period
included
$39.6
million
of
debt
service
and
interest,
$8.5
million
in
the
Petrosud
acquisition
and
$6.2
million
to
repurchase
shares
under
the
company's
current
NCIB
program.
The
company's
restricted
cash
position
as
at
December
31, 2021,
was
$63.3
million,
down
37%
compared
to
the
prior
quarter.
The
$37.4
million
decrease
in
restricted
cash
quarter-over-quarter
is
primarily
due
to
the
release
of
approximately
$28.9
million
related
to
the
Bicentenario
Pipeline
Settlement
Agreement.
In
2021,
the
company
released
approximately
$105.6
million
of
restricted
cash.
The
company
anticipates
releasing
additional
restricted
cash
in
the
second
quarter
of
2022
as
the
company
continues
to
optimize
its
credit
line.
Cash
provided
by
operating
activities
was
$113.5
million
in
the
fourth
quarter
of
2021,
a
43%
increase
compared
to
the
prior
quarter.
At
December
31, 2021,
the
company
had
a
total
inventory
balance
of
807,061 barrels.
Sales
volumes
net
of
purchases
in
the
fourth
quarter
increased
by
46%
compared
to
the
prior
quarter,
reducing
the
inventory
volume
in
Colombia
in
the
quarter.
The
company
has
various
uncommitted
bilateral
credit
lines.
As
of
December
31, 2021,
the
company
had
increased
its
uncollateralized
credit
line
to
$89.6
million,
an
increase
of
$69.6
million
compared
to
December 31, 2020.
Subsequent
to
the
quarter,
the
company
has
continued
to
increase
its
credit
line
by
approximately
$16
million.
Frontera
currently
has
uncollateralized
credit
line
in
excess
of
$100 million.
Under
the
company's
current NCIB,
the
company
repurchased
for
cancellation
989,300
common
shares
during
the
fourth
quarter
at
a
cost
of
approximately
$6.2
million.
As
of
March
1, 2022,
the
company
has
repurchased
approximately
4.1
million
common
shares
for
cancellation
for
approximately
$23
million.
The
company
intends
to
renew
its
NCIB
when
it
expires
on
March
16, 2022,
to
permit
purchases
for
up
to
10%
of
its
outstanding
float
over
the
next
year.
Renewal
of
the
NCIB
program
remains
subject
to
acceptance
by
the
Toronto
Stock
Exchange.
Capital
expenditures
were
$135.5
million
in
the
fourth
quarter
of
2021
compared
to
$103.2
million
in
the
prior
quarter.
The
company
executed
approximately
$314.3
million
in
total
capital
spending
in
2021
compared
to
$108.1
million
in
2020. The
increase
in
capital
expenditures
in
the
fourth
quarter
compared
to
the
prior
quarter
was
primarily
due
to
increased
development
drilling
and
increased
exploration
activity
in
Guyana,
Colombia
and
Ecuador.
The
company recorded
net
income
of
$629.4
million
or
$6.6
per
share
in
the
fourth
quarter
of
2021
compared
with
net
income
of
$38
million
(sic)
[$38.5
million]
(00:24:32) or $0.40
per
share in the prior quarter.
Net
income
for
the
year
was
$628.1
million
or
$6.50
per
share
in
2021
compared
with
a
net
loss
of
$497.4
million
or
$5.13
per
share
in 2020.
The
increase
in
net
income
quarter-over-quarter
was
mainly
due
to
the
reversal
of
impairment,
the
recognition
of
additional
deferred
tax
assets,
the
increase
in
Brent
oil
prices
and
additional
volumes
sold
at
the
end
of
the
year.
The
increase
in
net
income
year-over-year
was
mainly
due
to
the
reversal
in
impairments
and
the
recognition
of
additional
deferred
tax
assets.
The
company's operating
net
back
was
$47.8
per
boe,
up
26%
compared
to
the
prior
quarter,
primarily
due
to
higher
net
sales
realized
price
and
reduction
in
transportation
costs
mainly
due
to
the
recognition
of
prepaid
services
of
the
Bicentenario
system,
partially
offset
by
the
increase
in
production
costs,
mainly
due
to
higher
well
services,
maintenance
activities
and
the
increase
in
power
generation
and
communities
cost.
The
company's net
sales
realized
price
was
$69.53
per
boe
in
the
fourth
quarter,
up
17%
compared
to
the
prior
quarter.
The
increase
was
primarily
driven
by
higher
Brent
oil
prices,
higher
volumes
sold,
lower
cost
of
risk
management
contracts
and
lower
royalties
per
boe
during
the
fourth
quarter
of
2021.
Production
costs
averaged
$12.71
per
boe
in
the
fourth
quarter,
up
11%
compared
to
the
prior
quarter.
The
increase
in
production cost
was
mainly
due
to
additional
activities,
maintenance
activities
and
the
increase
in
power
supply
and communities
costs. Frontera's
production
costs
averaged
$11.46
in
2021,
at
the
high
end
of
our
2021
guidance
range
of
$10.50
to
$11.50
per
boe.
Transportation
costs
averaged
$9.02
per
boe,
down
12%
compared
to
the
prior
quarter.
Frontera's
transportation
costs
averaged
$10.43
per
boe,
within
its
2021
guidance
range
of
$10
to
$11
per
boe.
The
company
recorded
a
realized
loss
on
risk
management
contracts
of
$6.7
million
in
the
fourth
quarter
of
2021,
virtually
flat
compared
to
the
prior
quarter.
The
realized
loss
on
risk
management
contracts
was
primarily
due
to
the
cash
settlement
on
three-way
collars, puts
and
put
spreads
contracts
paid
during
the
quarter
at
an
average
price
of
$79.66
per
barrel.
Subsequent
to
December
31, 2021,
the
company
entered
into
new
put hedges,
so
the
current
hedge
portfolio
protects
approximately
40%
of
2022
estimated
production
up
until
September
2020 (sic) [September 2022] (00:28:21)
at
a
$70
per
barrel
price
with
no
ceiling,
allowing
the
company
to
fully
benefit
from
higher
oil
prices.
In
other
words,
the
company's
first
quarter
2022
hedges
do
not
cap
any
upside
potential,
and
not
any
of
the
subsequent
quarters
as
well.
I
would
now
like
to
turn
the
call
back
over
to
our
CEO.
Orlando?
O
Orlando Cabrales Segovia
Thank
you. Thank you, Alejandro.
So
as you
have
heard Frontera
had
a
very
busy
and
successful
fourth
quarter
and
full-year
in
2021.
Looking
ahead,
I'm
very
excited
about
our
2022
capital
and production
plans,
which
optimizes
both
capital
efficiency
and
free
cash
flow
after
development
CapEx
in
2022
and
beyond
built
on
the
significant
progress
the
company
made
in
2021
on
its
objectives
and
maintains
a
disciplined
approach
to
spending
in
the
face
of
increasing
inflationary
pressures.
For
Frontera
2022
capital
program
is
self-funded
at
$70
per
barrel
Brent
prices,
and
is
focused
on
two
key
areas.
First,
we
anticipate
spending 225 –
between
$225
million
and
$255
million
in
our
Colombian
and
Ecuador
upstream
business
to
deliver
full-year
production
between 40,000
and
43,000
boes
per
day,
a
10%
year-over-year
increase
at
the
midpoint.
We
will
capitalize
on
the
sweet
spots
of
our
portfolio
by
investing
in
development facilities
at
VIM-1,
drilling
opportunities
at
the
recently
acquired
Petrosud
assets,
development
drilling
at
Quifa,
exploration
activities
and
maintenance
and
production
integrity
activities
across
our
portfolio.
The
activity
is
also
expected
to
create
a
platform
for
future
growth
in
2023
and
beyond.
Second,
Frontera
and
CGX
anticipate
a
spending
between
$110 million
and
$130
million
on
Guyana
exploration,
primarily
to
drill
Wei-1,
our
second
high
impact
exploration
well
in
the
most
exciting
offshore
base
in
the
world. CGX
anticipates
spending
[indiscernible]
(00:31:22)
$5
million
to
$10
million
on
Guyana
infrastructure to
advance the
Berbice Deep
Water
Port
project.
We
anticipate
generating
operating
EBITDA
of
$375
million
to
$435
million
at
$70
per
barrel
Brent
prices, $475
million
to
$525
million
at
$80
per
barrel
Brent
prices
and $575
million
to
$625
million
at
$90
per
barrel
Brent
prices
which
demonstrates
our
upside
to
higher
oil
prices.
Additionally,
we
anticipate
continuing
to
enhance
shareholder
returns
through
our
NCIB,
which
the
company
intends
to
renew
when
our
existing
NCIB
expires
later
this
month
to
permit purchases
of
up
to
10%
of
its
public
float
over
the
next
year.
With
that,
I
would
like
to
conclude
by
saying
thank
you
to
Gabriel and
Alejandro
for
their
comments
and
thank
you
everyone
for
attending
our
call.
I
will
now
turn
the
call
back
to
our
operator
who
will
open
the
call
up
for
questions.
Operator
Thank
you.
[Operator Instructions]
Our
first
question
comes
from the
line
of
Ezequiel
Fernández
with
Balanz.
Please
go
ahead.
E
Ezequiel Fernández
Analyst, Balanz Capital Valores SA
Hi.
This
is Ezequiel
Fernández
from
Balanz.
Thanks
for
taking
my
question
and
the
materials
for
the
quarter. My
first
question is related
that
Frontera
seems
to
be
a
bit
below
the
customary
hedging
level
as a
percentage
of
output
right
now
which
of
course
has
turn
out
to
be
a
favorable
thing,
and –
I
mean
if
we
are
not
mistaken
about
that
and
for
how
long
are
you
aiming
to
remain
more
exposed
to
spot
pricing
than
usual?
A
Alejandro Piñeros
Chief Financial Officer, Frontera Energy Corp.
Thank
you
for
the
question Ezequiel.
This
is
Alejandro.
I
think
we
have
exposure
to
the
upside.
We
have
protected
the
downside.
Right
now
we
have
naked
put in
place
up
until
the
third
quarter
of
2022
with
a
floor
of
$70
per
barrel
which
allows
us
to
protect
our
program –
our
plan
and
as
well
as
our
capital
program
for
2022.
I
think
that
the
strategy –
the
hedging
strategy
for
Frontera
is
to
cover
40%
or
at
least
40%
of
production
over
the
next
year.
Protecting
the
downside,
I'm
looking
for –
to
provide
exposure
to
upside
in
Brent
prices.
So,
currently
we
are
exposed
to
the
spot
price,
which
has
been
increasing
significantly
and
we
are
realizing
the
benefits
or
the
full
benefit
of
the
increase
in
oil
prices
in
2022. In
this
current
price
environment,
we
are
satisfied
with
that
approach.
And
we
will
continue
to
execute
our
hedging
strategy
according
to
this
approach.
E
Ezequiel Fernández
Analyst, Balanz Capital Valores SA
Great.
That's
great.
I
have
a
second
question
related
to
your
gas
plants
in
Colombia.
I
know
that
at
the
moment
it's
not
such
a
relevant
operation,
at
least
not
the
biggest
contributor
to
revenues,
but
it's
interesting
because
prices
on
the
domestic
gas
market
are
pretty
good,
$4.5
per
MMBtu
or
so.
So
if
you
could
share
with
us
maybe
a
little
bit
of
what
you're
trying
to
do
with
VIM-1
and
the
new
acquired
areas
in
terms
of
target
output,
if
that
production
is
going
to
be
connected
to
the
Promigas
pipeline
or
the
TGI
pipeline
if
you're
looking
for
some
contracts
or
to
remain
on
the
spot
basically
at?
O
Orlando Cabrales Segovia
Okay.
Thank
you. Thank
you
Ezequiel.
Well,
I
think
as
you
implied
in
your
question,
I
mean
the
gas
market
in
Colombia
I
mean
represents
a
good
opportunity
for
the
company.
That
is
why
we
were,
I
mean,
very
keen
to
start
the
production
at
La Belleza
discovery
in
the
fourth
quarter
of
last
year.
In
addition
to
that,
that
was
something
very
fundamental
part
of
the
rationale
behind
the
acquisition
of
Petrosud.
So
that
will
I
mean
increase
our – the
participation
of
natural
gas
in
our
portfolio.
And
I
can
tell
you
that
most
of
that
production
is
being
sold
to
a
market
under
contracts,
under
fixed term
contracts,
so
just
to
take
advantage
of
the
increasing
prices
in
the
market.
E
Ezequiel Fernández
Analyst, Balanz Capital Valores SA
Okay.
And
a
follow-up
on
that
one.
How
are
you
selling
that
gas
in
terms
of
transporting
it?
Is
it
connected
to
a
pipe?
Does
it
go
by
truck?
O
Orlando Cabrales Segovia
It
is
connected
to
the
National
System,
to
the
transportation
system.
So
both –
I
mean
both
Petrosud
is
connected
to
the
system
and
La
Belleza
– the gas
production
at
La
Belleza
is
being
sold
as compressed
natural
gas.
E
Ezequiel Fernández
Analyst, Balanz Capital Valores SA
Okay.
Perfect.
And
the
one
that
is
connected
to
the
gas
pipes,
is
that
the
Promigas
or
the
TGI
pipes?
O
Orlando Cabrales Segovia
That
is
[indiscernible]
(00:38:11)
pipeline.
E
Ezequiel Fernández
Analyst, Balanz Capital Valores SA
Oh,
okay.
So
it's
the
[indiscernible]
(00:38:18)
and
then
it
goes
to
Colombia. So,
okay
great.
And
I
have
a
final question...
O
Orlando Cabrales Segovia
Yeah. Exactly
yeah.
E
Ezequiel Fernández
Analyst, Balanz Capital Valores SA
Okay.
And
I have
a
final
question
that – maybe
it's
a
little
bit
hard
to
answer
right
now,
but
I'll
give
it
a
try.
You
probably –
you're
unlocking
some
restricted
cash
next
quarter,
as
you
mentioned,
and
you're
going to
have
a
pretty
good
operational
year.
So
based
on
your
base
case
where
do
you expect
your
cash
position
to
end
this
year?
A
Alejandro Piñeros
Chief Financial Officer, Frontera Energy Corp.
I
think
we're
not
– Ezekiel, this
is
Alejandro.
We're
not
disclosing
projected cash.
What
I
can
say
is
that
you're
right
that
we
are
generating
significant
cash.
As
Orlando
pointed
out
at
$90
Brent
average,
our
EBITDA
guidance
midpoint
is
around
$600
million.
So
we
are
in
a
position
to
generate
significant
cash
throughout
the
year,
not
only
through
operational
and
cash
generation
but
also
through
the
release
of
additional
cash.
As
Orlando
also
mentioned
our
capital
program
is
self-funded
at
$70
Brent, so
anything
above
and
beyond
will
be
additional
cash
that
we
are
generating
in
the
company.
And
as
I
mentioned
before,
we
have
[indiscernible]
(00:39:55)
of
the
company
to
higher
oil
prices
is
significant.
E
Ezequiel Fernández
Analyst, Balanz Capital Valores SA
Okay.
That's
great.
That's
all
from
my
side.
Thank
you
very
much.
O
Orlando Cabrales Segovia
Thank
you
Ezequiel.
Operator
Thank
you.
[Operator Instructions]
Our
next –
my
apologies.
There
are
no further
questions
at
this
time.
Should
you
have
any
further
questions,
please
email
ir@fronteraenergy.ca.
This
concludes
the
call.
Thank
you
for
your
participation.
Good morning. My name is Lorrie, and I'll be your conference facilitator today. Welcome to Frontera Energy's Fourth Quarter 2021 and Year-End Operating and Financial Results Conference Call. All lines are currently on mute to prevent any background noise. The call is scheduled for 60 Minutes. I would like to remind you that this conference call is being recorded today, and it's also available through audio webcast on the company's website. After the speakers' remarks, there will be time for questions. Analysts and investors are reminded that any additional questions can be directed to the company at ir@fronteraenergy.ca. This call contains forward-looking information within the meaning of applicable Canadian security laws relating to activities, events or developments the company believes or expects will or may occur in the future. Forward-looking information reflects the current expectations, assumptions and beliefs of the company based on information currently available to it.
Also, the company believes the assumptions are reasonable. Forward-looking information is not a guarantee of future performance. Forward-looking information is subject to a number of risks and uncertainties that may cause the actual results of the company to differ materially from those discussed in the forward-looking information.
The company's MD&A for the year ended December 31, 2021, and the company's Annual Information Form dated March 2, 2022, and other documents it files from time to time with securities regulatory authorities describe the risks, uncertainties, materials assumptions and other factors that could influence actual results. Any forward-looking information speaks only as of the date on which it is made and the company disclaims any intent or obligation to update any forward-looking information except as required by law.
I would now like to turn the call over to Mr. Gabriel de Alba, Chairman of the Board of Frontera Energy. Please go ahead, sir.
Thank you operator and thank you everyone for joining today's conference call to review Frontera's fourth quarter and year-end operating and financial results. Joining me on the call are Orlando Cabrales, Frontera's CEO; Alejandro Piñeros, Frontera's CFO. Also available to answer questions at the end of the call, we have Victor Vega, VP of Field Development, Reservoir Management and Exploration; and Regan Palsgrove, Head of Exploration.
Frontera continues to deliver on its strategic, operational and financial objectives. In 2021, the company generated $373.2 million of EBITDA, an increase of 117% compared to 2020 and within the company's tightened and increased full-year operating EBITDA guidance range. Frontera averaged 37,818 barrels per day, in line with 2021 guidance.
Frontera recorded net income of $628.1 million in 2021, primarily due to impairment reversals. The company released approximately $105.6 million of restricted cash, increased its uncollateralized credit lines to $89.6 million at year-end and repurchased approximately 3.86 million or 7.4% of its public float for cancellation for approximately $21.5 million under its current NCIB as of December 31, 2021.
The company completed the pipeline Conciliation Agreement, which eliminated more than $1 billion in contingent liabilities. Frontera's production costs averaged $11.46 per barrel and its transportation costs averaged $10.43 per barrel, both within its 2021 guidance ranges. Importantly, Frontera achieved 98% of its 2021 ESG goals, including offsetting 41% of its emissions through carbon credits and preserving and restoring 765 new hectares of key connectivity corridors in Casanare and Meta Departments in Colombia.
I'm extremely proud of our fourth quarter and year-end 2021 results. I would like to acknowledge the hard work and dedication of entire Frontera team, its management and its Board of Directors for their efforts in helping the company achieve such positive results.
I will now turn the call over to Orlando Cabrales, Frontera's CFO (sic) [Frontera's CEO] (00:05:02); and our CFO, Alejandro Piñeros, who will share their views on our fourth quarter and year-end results. Orlando?
Thank you Gabriel and good morning, everyone. Frontera delivered strong fourth quarter financial and operational results. Production averaged 88,605 boe per day (sic) [38,605 boe per day] (00:05:24), up 6% compared to the previous quarter, and the company's year-end production exit rate was 40,457 boe per day excluding Petrosud, in line with the company's production guidance.
Frontera's daily production on March 1 of this year was approximately 42,000 boe per day and the company's year-to-date average production is approximately 40,500 boe per day. During the fourth quarter, Frontera began early production of 2,400 boe per day plus at La Belleza discovery on VIM-1, acquired 100% of the issued and outstanding shares in Petrosud, which added 1,300 boe per day of production. We also signed an agreement to acquire the remaining 35% interest in el Dificil block held by PCR, which will add an additional 500 boe per day of production when the deal closes in the second half of this year. We also discovered hydrocarbon bearing reservoirs in multiple formations at the Jandaya-1 exploration well in Ecuador. Subsequent to year-end we were awarded Block VIM-46 in the 2021 Colombia Bid Round. And importantly, we announced that our JV in Guyana had discovered approximately 200 feet of net pay with multiple horizons at the company's potentially transformational Kawa-1 exploration well, offshore Guyana.
Compared to the prior quarter, cash provided by operating activities increased by 43%. The company's operating netback increased by 26%. Our net sales realized price increased 17% and the company's transportation cost per barrel decreased 12%. Operationally, in the fourth quarter of 2021, the company drilled 14 development wells, including 12 at Quifa and 2 at Guatiquia and completed 56 workovers and well services at Quifa, Guatiquia, Canaguaro, Abanico, Corcel, Cajua, Cravoviejo, Cubiro and Casimena. In 2021, the company drilled 42 producer wells, 3 injector wells and completed 148 workovers and well services.
We also delivered solid results in 2021. The company replaced 157% of net 1P reserves and 105% of net 2P reserves and extended our net 1P reserve life index to 8.7 years and our net 2P reserve life index to 13.3 years. We increased our net 2P natural gas and associated natural gas liquid reserves by 105% to [ph] 19-point million boe (00:09:25) further diversifying Frontera's future production mix. The net present value at a 10% discount on December 31, 2021, of the company's 2P reserves increased by 61% to $3,036 million before tax due in part to higher Brent prices year-over-year, but also greater operational and development cost stability.
I would talk about our Colombian operational activities in more detail in a minute, but first let me spend a few moments discussing our potentially transformational Kawa-1 exploration well in offshore Guyana. Frontera, through its joint venture with CGX in the Corentyne block offshore Guyana have safely completed exploration activities at the Kawa-1 exploration well. In line with our exploratory objectives, the well has now been safely plugged and abandoned and the Maersk Discover drilling rig has been released from the Kawa-1 location. Only a single lost time injury was recorded throughout Kawa-1 well operations. The final cost of the Kawa-1 exploration well was $141 million.
The Kawa-1 well was drilled to a total depth of 21,578 feet in the northern section of the Corentyne block. Drilling results confirm the presence of an active hydrocarbon system at the Kawa-1 location. Successful wireline logging runs confirmed net pay of approximately 200 feet within the Maastrichtian, the Campanian, the Santonian and the Coniacian horizons. These intervals are similar in age and can be correlated using regional seismic data to recent successes in Block 58 in Suriname and Stabroek Block in Guyana.
The JV did not get MDT data or sidewall core samples and has engaged an independent third-party to complete further detailed studies and laboratory analysis on drilling cuttings from the Santonian, Campanian and Maastrichtian intervals and well-bore fluid samples to evaluate in situ hydrocarbons. Preliminary results from the Santonian interval indicate the presence of liquid hydrocarbons in the reservoir. Results from the Campanian and Maastrichtian intervals are pending.
Kawa-1 well results have improved the JV understanding of the operational and geological complexities of the basin and will help reduce the technical risks of the Wei-1 exploration well. Given the initial positive results at the Kawa-1 well the JV is moving forward with its second exploration well, Wei-1 on the Corentyne block.
The JV has begun the integration of detailed seismic and lithological analysis and pore pressure studies from the Kawa-1 well into drilling preparations in advance of spudding the Wei-1 exploration well which will be spud in the second half of 2022. The Wei-1 exploration well will target Campanian and Santonian aged stacked channels in the western fan complex in the northern section of the Corentyne block. Data from both the Kawa-1 and Wei-1 wells will inform future activities and potential appraisal/development decisions.
On February 14, 2022, the JV announced that as a result of the initial positive results at the Kawa-1 exploration well, the JV will focus on the significant exploration opportunities in the Corentyne block and will not engage in drilling activities on the Demerara block in 2022. CGX is currently assessing several strategic opportunities to obtain additional financing to meet the costs of the drilling program.
Now, I would like to discuss production on our Colombian operations. Production averaged 38,605 boe per day in the fourth quarter, up 6% compared to the prior quarter. Currently, the company has five drilling rigs, five workover rigs active at its Quifa, Coralillo, Corcel, Copa and Guaduas operations in Colombia and at the Perico block in Ecuador. At Quifa, current production is approximately 16,100 barrels per day of heavy crude oil. The company drills 12 development wells at Quifa in the fourth quarter of 2021. In total, the company drilled 25 development wells and 2 injector wells at Quifa in 2021. Frontera also continued to recover water disposal levels in the fourth quarter by performing interventions in storm water disposal wells at different injection layers.
At Guatiquia, current production is approximately 9,400 barrels per day of light and medium crude oil. The company successfully completed the Coralillo-9 well in the fourth quarter which is currently producing 700 barrels per day. Frontera also completed Coralillo-15 in the fourth quarter which began production of 600 barrels per day in January of this year.
At CPE-6, current production is approximately 5,000 barrels per day of heavy crude oil. In the fourth quarter, we began operations on our facilities expansion strategy.
On the VIM-1 Block, production from La Belleza discovery began on November 8, 2021, with gross rates of approximately 2,400 boe per day. The Planadas-1 exploration well was drilled to a measured depth of 13,700 feet, but yielded no hydrocarbons.
Turning our attention to Ecuador. On December 7 of last year, Frontera spud the Jandaya-1 exploration well on the Perico block in Ecuador. This was among the first wells drilled in the country on acreage awarded through the 2019 Intracampos Bid Round. The well was drilled to a total depth of 10,975 feet encountering a total of 78 feet vertical depth of potential hydrocarbon bearing reservoir in three formations. Production tests in the lower Hollin formation have produced 882 barrels per day with a 1.7% water cut, after 29 days of testing. Development planning activities and permitted work is under way in advance of long-term testing of at least six months or a longer period of time if approved by authorities.
On January 28 of this year, Frontera spud its second exploration well called Tui-1 in the southern portion of the Perico block. The Tui-1 exploration well is expected to be drilled to a total debt of 10,972 feet and is targeting the same formations as the Jandaya-1 well. Additional prospects on the Perico block have been identified and are being matured for future drilling. Frontera's acreage position and initial positive results in Ecuador provided the company with flexibility, optionality and a potential future platform for growth.
I would now like to turn the call over to Alejandro Piñeros, Frontera's CFO, to discuss our fourth quarter and year-end financial results.
Thank you, Orlando. Frontera's operating EBITDA was $148.3 million in the fourth quarter, up 104% compared to the prior quarter. The increase quarter-over-quarter was primarily as a result of two more cargoes sold during the fourth quarter of 2021. Frontera generated $373.2 million of EBITDA in 2021, up 117% compared to 2020 and in line with guidance of $360 million to $380 million. The company's total cash position as at December 31, 2021, was $320.8 million compared to $419.5 million at September 30, 2021. Cash utilization during the period included $39.6 million of debt service and interest, $8.5 million in the Petrosud acquisition and $6.2 million to repurchase shares under the company's current NCIB program.
The company's restricted cash position as at December 31, 2021, was $63.3 million, down 37% compared to the prior quarter. The $37.4 million decrease in restricted cash quarter-over-quarter is primarily due to the release of approximately $28.9 million related to the Bicentenario Pipeline Settlement Agreement. In 2021, the company released approximately $105.6 million of restricted cash. The company anticipates releasing additional restricted cash in the second quarter of 2022 as the company continues to optimize its credit line.
Cash provided by operating activities was $113.5 million in the fourth quarter of 2021, a 43% increase compared to the prior quarter. At December 31, 2021, the company had a total inventory balance of 807,061 barrels. Sales volumes net of purchases in the fourth quarter increased by 46% compared to the prior quarter, reducing the inventory volume in Colombia in the quarter.
The company has various uncommitted bilateral credit lines. As of December 31, 2021, the company had increased its uncollateralized credit line to $89.6 million, an increase of $69.6 million compared to December 31, 2020. Subsequent to the quarter, the company has continued to increase its credit line by approximately $16 million. Frontera currently has uncollateralized credit line in excess of $100 million.
Under the company's current NCIB, the company repurchased for cancellation 989,300 common shares during the fourth quarter at a cost of approximately $6.2 million. As of March 1, 2022, the company has repurchased approximately 4.1 million common shares for cancellation for approximately $23 million. The company intends to renew its NCIB when it expires on March 16, 2022, to permit purchases for up to 10% of its outstanding float over the next year. Renewal of the NCIB program remains subject to acceptance by the Toronto Stock Exchange.
Capital expenditures were $135.5 million in the fourth quarter of 2021 compared to $103.2 million in the prior quarter. The company executed approximately $314.3 million in total capital spending in 2021 compared to $108.1 million in 2020. The increase in capital expenditures in the fourth quarter compared to the prior quarter was primarily due to increased development drilling and increased exploration activity in Guyana, Colombia and Ecuador.
The company recorded net income of $629.4 million or $6.6 per share in the fourth quarter of 2021 compared with net income of $38 million (sic) [$38.5 million] (00:24:32) or $0.40 per share in the prior quarter. Net income for the year was $628.1 million or $6.50 per share in 2021 compared with a net loss of $497.4 million or $5.13 per share in 2020. The increase in net income quarter-over-quarter was mainly due to the reversal of impairment, the recognition of additional deferred tax assets, the increase in Brent oil prices and additional volumes sold at the end of the year. The increase in net income year-over-year was mainly due to the reversal in impairments and the recognition of additional deferred tax assets.
The company's operating net back was $47.8 per boe, up 26% compared to the prior quarter, primarily due to higher net sales realized price and reduction in transportation costs mainly due to the recognition of prepaid services of the Bicentenario system, partially offset by the increase in production costs, mainly due to higher well services, maintenance activities and the increase in power generation and communities cost.
The company's net sales realized price was $69.53 per boe in the fourth quarter, up 17% compared to the prior quarter. The increase was primarily driven by higher Brent oil prices, higher volumes sold, lower cost of risk management contracts and lower royalties per boe during the fourth quarter of 2021.
Production costs averaged $12.71 per boe in the fourth quarter, up 11% compared to the prior quarter. The increase in production cost was mainly due to additional activities, maintenance activities and the increase in power supply and communities costs. Frontera's production costs averaged $11.46 in 2021, at the high end of our 2021 guidance range of $10.50 to $11.50 per boe.
Transportation costs averaged $9.02 per boe, down 12% compared to the prior quarter. Frontera's transportation costs averaged $10.43 per boe, within its 2021 guidance range of $10 to $11 per boe. The company recorded a realized loss on risk management contracts of $6.7 million in the fourth quarter of 2021, virtually flat compared to the prior quarter. The realized loss on risk management contracts was primarily due to the cash settlement on three-way collars, puts and put spreads contracts paid during the quarter at an average price of $79.66 per barrel.
Subsequent to December 31, 2021, the company entered into new put hedges, so the current hedge portfolio protects approximately 40% of 2022 estimated production up until September 2020 (sic) [September 2022] (00:28:21) at a $70 per barrel price with no ceiling, allowing the company to fully benefit from higher oil prices. In other words, the company's first quarter 2022 hedges do not cap any upside potential, and not any of the subsequent quarters as well.
I would now like to turn the call back over to our CEO. Orlando?
Thank you. Thank you, Alejandro. So as you have heard Frontera had a very busy and successful fourth quarter and full-year in 2021. Looking ahead, I'm very excited about our 2022 capital and production plans, which optimizes both capital efficiency and free cash flow after development CapEx in 2022 and beyond built on the significant progress the company made in 2021 on its objectives and maintains a disciplined approach to spending in the face of increasing inflationary pressures.
For Frontera 2022 capital program is self-funded at $70 per barrel Brent prices, and is focused on two key areas. First, we anticipate spending 225 – between $225 million and $255 million in our Colombian and Ecuador upstream business to deliver full-year production between 40,000 and 43,000 boes per day, a 10% year-over-year increase at the midpoint. We will capitalize on the sweet spots of our portfolio by investing in development facilities at VIM-1, drilling opportunities at the recently acquired Petrosud assets, development drilling at Quifa, exploration activities and maintenance and production integrity activities across our portfolio. The activity is also expected to create a platform for future growth in 2023 and beyond.
Second, Frontera and CGX anticipate a spending between $110 million and $130 million on Guyana exploration, primarily to drill Wei-1, our second high impact exploration well in the most exciting offshore base in the world. CGX anticipates spending [indiscernible] (00:31:22) $5 million to $10 million on Guyana infrastructure to advance the Berbice Deep Water Port project.
We anticipate generating operating EBITDA of $375 million to $435 million at $70 per barrel Brent prices, $475 million to $525 million at $80 per barrel Brent prices and $575 million to $625 million at $90 per barrel Brent prices which demonstrates our upside to higher oil prices. Additionally, we anticipate continuing to enhance shareholder returns through our NCIB, which the company intends to renew when our existing NCIB expires later this month to permit purchases of up to 10% of its public float over the next year.
With that, I would like to conclude by saying thank you to Gabriel and Alejandro for their comments and thank you everyone for attending our call. I will now turn the call back to our operator who will open the call up for questions.
Thank you. [Operator Instructions] Our first question comes from the line of Ezequiel Fernández with Balanz. Please go ahead.
Hi. This is Ezequiel Fernández from Balanz. Thanks for taking my question and the materials for the quarter. My first question is related that Frontera seems to be a bit below the customary hedging level as a percentage of output right now which of course has turn out to be a favorable thing, and – I mean if we are not mistaken about that and for how long are you aiming to remain more exposed to spot pricing than usual?
Thank you for the question Ezequiel. This is Alejandro. I think we have exposure to the upside. We have protected the downside. Right now we have naked put in place up until the third quarter of 2022 with a floor of $70 per barrel which allows us to protect our program – our plan and as well as our capital program for 2022. I think that the strategy – the hedging strategy for Frontera is to cover 40% or at least 40% of production over the next year. Protecting the downside, I'm looking for – to provide exposure to upside in Brent prices. So, currently we are exposed to the spot price, which has been increasing significantly and we are realizing the benefits or the full benefit of the increase in oil prices in 2022. In this current price environment, we are satisfied with that approach. And we will continue to execute our hedging strategy according to this approach.
Great. That's great. I have a second question related to your gas plants in Colombia. I know that at the moment it's not such a relevant operation, at least not the biggest contributor to revenues, but it's interesting because prices on the domestic gas market are pretty good, $4.5 per MMBtu or so. So if you could share with us maybe a little bit of what you're trying to do with VIM-1 and the new acquired areas in terms of target output, if that production is going to be connected to the Promigas pipeline or the TGI pipeline if you're looking for some contracts or to remain on the spot basically at?
Okay. Thank you. Thank you Ezequiel. Well, I think as you implied in your question, I mean the gas market in Colombia I mean represents a good opportunity for the company. That is why we were, I mean, very keen to start the production at La Belleza discovery in the fourth quarter of last year. In addition to that, that was something very fundamental part of the rationale behind the acquisition of Petrosud. So that will I mean increase our – the participation of natural gas in our portfolio. And I can tell you that most of that production is being sold to a market under contracts, under fixed term contracts, so just to take advantage of the increasing prices in the market.
Okay. And a follow-up on that one. How are you selling that gas in terms of transporting it? Is it connected to a pipe? Does it go by truck?
It is connected to the National System, to the transportation system. So both – I mean both Petrosud is connected to the system and La Belleza – the gas production at La Belleza is being sold as compressed natural gas.
Okay. Perfect. And the one that is connected to the gas pipes, is that the Promigas or the TGI pipes?
That is [indiscernible] (00:38:11) pipeline.
Oh, okay. So it's the [indiscernible] (00:38:18) and then it goes to Colombia. So, okay great. And I have a final question...
Yeah. Exactly yeah.
Okay. And I have a final question that – maybe it's a little bit hard to answer right now, but I'll give it a try. You probably – you're unlocking some restricted cash next quarter, as you mentioned, and you're going to have a pretty good operational year. So based on your base case where do you expect your cash position to end this year?
I think we're not – Ezekiel, this is Alejandro. We're not disclosing projected cash. What I can say is that you're right that we are generating significant cash. As Orlando pointed out at $90 Brent average, our EBITDA guidance midpoint is around $600 million. So we are in a position to generate significant cash throughout the year, not only through operational and cash generation but also through the release of additional cash. As Orlando also mentioned our capital program is self-funded at $70 Brent, so anything above and beyond will be additional cash that we are generating in the company. And as I mentioned before, we have [indiscernible] (00:39:55) of the company to higher oil prices is significant.
Okay. That's great. That's all from my side. Thank you very much.
Thank you Ezequiel.
Thank you. [Operator Instructions] Our next – my apologies. There are no further questions at this time. Should you have any further questions, please email ir@fronteraenergy.ca. This concludes the call. Thank you for your participation.
Thank you.
Thank you very much.